Using seabed sensors and sea-surface reflections for structural imaging of a subsurface location in a geological formation

ABSTRACT

The present disclosure provides a technique for marine seismic imaging that processes data acquired from two or more different seismic surveys in a combined manner to advantageous effect. The different seismic surveys may use seabed sensors at same positions on the seabed, but they may have different shot locations and may be performed at different times. In one use case, the technique may be used to image a subsurface location that is difficult to image using either survey alone. In another use case, the technique may be used to image a subsurface location under an obstruction. The technique may also be utilized to efficiently monitor a reservoir over time.

CROSS-REFERENCE TO RELATED APPLICATION(S)

This application is a divisional application of U.S. patent applicationSer. No. 15/166,902, filed on May 27, 2016, the disclosure of which ishereby incorporated by reference. U.S. patent application Ser. No.15/166,902 claims the benefit of U.S. Provisional Application No.62/168,988, filed on Jun. 1, 2015, which is incorporated by referenceherein in its entirety.

BACKGROUND

Geophysical surveys are often used for oil and gas exploration ingeological formations, which may be located below marine environments.Various types of signal sources and geophysical sensors may be used indifferent types of geophysical surveys.

Seismic geophysical surveys, for example, are based on the use ofacoustic waves. In a marine seismic survey, a survey vessel may tow anacoustic source (e.g., an air gun or a marine vibrator) and a pluralityof streamers along which a number of acoustic sensors (e.g., hydrophonesand/or geophones) are located. Alternatively, acoustic sensors may belocated on the seabed rather than being towed.

Acoustic waves generated by the survey source may be transmitted to theEarth's crust and then reflected back and captured at the towed and/orseabed geophysical sensors. Data collected during a marine geophysicalsurvey may be analyzed to locate hydrocarbon-bearing geologicalstructures, and thus determine where deposits of oil and natural gas maybe located.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a diagram illustrating a geophysical survey system inaccordance with an embodiment of the invention.

FIG. 2 depicts an exemplary array of seabed sensors in accordance withan embodiment of the invention.

FIG. 3 is a flow chart of a method using seabed sensors and sea surfacereflections for structural imaging of a subsurface location in ageological formation in accordance with an embodiment of the invention.

FIG. 4A depicts shot locations of a first seismic survey (A) inaccordance with an embodiment of the invention.

FIG. 4B depicts shot locations of a second seismic survey (B) inaccordance with an embodiment of the invention.

FIG. 4C depicts wavefields from the first and second seismic surveys (Aand B) that are utilized in combination to image a subsurface location(P) in accordance with an embodiment of the invention.

FIG. 4D depicts virtual wavefields after reversal of source and sensordefinitions of FIG. 4C in accordance with an embodiment of theinvention.

FIG. 4E depicts the virtual wavefield utilized for imaging thesubsurface location (P) after deconvolution or cross-correlation isapplied to the virtual wavefields of FIG. 4D in accordance with anembodiment of the invention.

FIG. 5A depicts shot locations of a first seismic survey (A) inaccordance with an embodiment of the invention.

FIG. 5B depicts shot locations of a second seismic survey (B) in thepresence of a surface obstruction in accordance with an embodiment ofthe invention.

FIG. 5C depicts wavefields from the first and second seismic surveys (Aand B) that are utilized in combination to image a subsurface location(P) that may be underneath the obstruction in accordance with anembodiment of the invention.

FIG. 5D depicts virtual wavefields after reversal of source and sensordefinitions of FIG. 5C in accordance with an embodiment of theinvention.

FIG. 5E depicts the virtual wavefield utilized for imaging thesubsurface location (P) after deconvolution or cross-correlation isapplied to the virtual wavefields of FIG. 5D in accordance with anembodiment of the invention.

FIG. 6A depicts shot locations of a first seismic survey (A) inaccordance with an embodiment of the invention.

FIG. 6B depicts shot locations of a second seismic survey (B) withdifferent shot intervals than the first seismic survey (A) in accordancewith an embodiment of the invention.

FIG. 6C depicts wavefields from the first and second seismic surveys (Aand B) that are utilized in combination to image a subsurface location(P) in accordance with an embodiment of the invention.

FIG. 6D depicts virtual wavefields after reversal of source and sensordefinitions of FIG. 6C in accordance with an embodiment of theinvention.

FIG. 6E depicts the virtual wavefield utilized for imaging thesubsurface location (P) after deconvolution or cross-correlation isapplied to the virtual wavefields of FIG. 6D in accordance with anembodiment of the invention.

FIG. 7 is a flow chart of a method using seabed sensors and sea surfacereflections for reservoir production monitoring in accordance with anembodiment of the invention.

FIG. 8A depicts wavefields (A0 and A1) from a first seismic survey (A)at a first time that may be utilized in combination to image asubsurface location (P) at the first time in accordance with anembodiment of the invention.

FIG. 8B depicts virtual wavefields after reversal of source and sensordefinitions of FIG. 8A in accordance with an embodiment of theinvention.

FIG. 8C depicts the virtual wavefield utilized for imaging thesubsurface location (P) at the first time in accordance with anembodiment of the invention.

FIG. 8D depicts a wavefield (B1) from a second seismic survey (B) at asecond time that is utilized in combination with a wavefield (A0) fromthe first seismic survey (A) to image the subsurface location (P) at thesecond time in accordance with an embodiment of the invention.

FIG. 8E depicts virtual wavefields after reversal of source and sensordefinitions of FIG. 8D in accordance with an embodiment of theinvention.

FIG. 8F depicts the virtual wavefield utilized for imaging thesubsurface location (P) at the second time in accordance with anembodiment of the invention.

FIG. 8G depicts a wavefield (C1) from a third seismic survey (C) at athird time that is utilized in combination with a wavefield (A0) fromthe first seismic survey (A) to image the subsurface location (P) at thethird time in accordance with an embodiment of the invention.

FIG. 8H depicts virtual wavefields after reversal of source and sensordefinitions of FIG. 8G in accordance with an embodiment of theinvention.

FIG. 8I depicts the virtual wavefield utilized for imaging thesubsurface location (P) at the third time in accordance with anembodiment of the invention.

FIG. 9 shows a simplified example of a computer system which may be usedin performing processing steps in accordance with an embodiment of theinvention.

DETAILED DESCRIPTION

Three-dimensional (3D) seismic surveying generally uses one or moreacoustic (seismic) sources and an array of acoustic (seismic) sensors. Apattern of shots is performed by the source(s). For each shot, eachsensor in the array senses and records a seismic wavefield. The seismicdata obtained includes multiple seismic wavefields for each of multipleshots. The seismic data may be processed to create images of asubsurface volume underneath the array of sensors.

A 3D seismic survey design includes the positions of the shots and thelocations of the sensors. In the case of marine seismic surveying usingseabed sensors, the locations of the sensors are fixed. In that case,the positions of the shots (the shot survey) may be designed to obtainseismic data covering the desired subsurface volume.

Four-dimensional (4D) seismic surveying involves surveying the samegeological formation at different points in time. For example, 4Dsurveying may be used to determine changes over time in fluidsaturation, pressure, and so on. Because seabed sensors arefixed-position receivers that do not change position during the seismicacquisition, they may be redeployed at the same positions at a latertime so as to be advantageously used in 4D marine seismic surveying toreduce variations between surveys.

One problem or difficulty with marine seismic surveys may be caused byan obstruction that prevents positioning shots and/or sensors above atargeted sub-surface region. Such an obstruction makes it difficult toobtain seismic images of the sub-surface region under the obstruction ina conventional 3D or 4D seismic survey.

For example, a production platform may be located above the targetedsub-surface region. The production platform forms an obstruction thatblocks shots from being taken at sea-surface positions in the area abovethe targeted sub-surface region. In the case of towed sensors, theproduction platform may also block sensors from being towed above thetargeted region.

The present disclosure presents an innovative technique to generateseismic images by combining seismic data from different surveys. Thetechnique has various practical applications, such as imaging under anobstruction and efficient reservoir monitoring.

Exemplary Geophysical Survey System

Referring to FIG. 1, a diagram illustrating one embodiment of aGeophysical survey system 100 is shown. In the illustrated embodiment,the system 100 includes a survey vessel 10, signal source 32, andgeophysical sensors 22.

The survey vessel 10 may be configured to move along the surface 11 ofbody of water 15 such as a lake or the ocean, as shown. In theillustrated embodiment, signal source 32 is configured to transmit anacoustic signal. The illustrated dashed line shows a direction of travelfor a portion of an acoustic wave-front generated by signal source 32.In the illustrated embodiment, the acoustic signal proceeds through thesea floor 25 and is reflected by reservoir 120, the sea surface (anair/water interface) 11, and a reflector 27 located above reservoir 120.In other embodiments, the acoustic signal may be reflected from the seasurface multiple times (and reflected from the seabed in between the seasurface reflections).

Survey vessel 10 may include equipment, shown generally at 12 and forconvenience collectively referred to as “survey equipment.” Surveyequipment 12 may include devices such as a data recording unit formaking a record of signals generated by various geophysical sensors inthe system 100. Survey equipment 12 may also include navigationequipment, which may be configured to control, determine, and record, atselected times, the geodetic positions of: survey vessel 10, signalsource 32, and/or other survey elements. Geodetic position may bedetermined using various devices, including global navigation satellitesystems such as the global positioning system (GPS), for example. Insome embodiments, vessel 10 is configured to tow one or more seismicstreamers (not shown).

In the geophysical survey system 100 shown in FIG. 1, survey vessel 10tows a single signal source 32. In various embodiments, survey vessel 10may tow any appropriate number of signal sources, including as few asnone or as many as six or more. The location of the signal sources maybe centered behind survey vessel 10 or displaced from the center line,and may be at various distances relative to survey vessel 10, includingattached to the hull. Signal sources may be any type of signal sourceknown in the art. Signal source 32 may include an array of multiplesignal sources. For example, signal source 32 may include a plurality ofseismic sources (e.g., air guns). The term “signal source” may refer toa single signal source or to an array of signal sources. For example, inthe illustrated embodiment, signal sources 32 are each coupled to surveyvessel 10 at one end through winch 115 or a similar spooling device thatenables changing the deployed length of a signal source cable. Surveyequipment 12 may include signal source control equipment (not shownseparately) for selectively operating and maneuvering signal source 32.The specific configuration depicted in FIG. 1 is an example only. Otherconfigurations may be used for the geophysical survey system.

Geophysical sensors 22 may be referred to as seabed sensors and may beany type of geophysical sensor known in the art. In an exemplaryimplementation, the geophysical sensors may include pressure sensors(e.g., hydrophones) that measure pressure (P) as a scalar andparticle-velocity sensors (e.g. geophones and accelerometers) thatmeasure particle velocity (Z) as a vector. The pressure andparticle-velocity sensors may be both included in a given seabed sensor.Other examples of geophysical sensors that may be used includepressure-time-gradient responsive seismic sensors, electrodes,magnetometers, temperature sensors, fiber optic sensors, or combinationsof the foregoing. In various implementations of the disclosure,geophysical sensors 22 may measure, for example, seismic energyindicative of the response of various structures in the Earth'ssubsurface formation below the bottom 25 of body of water 15 to energyimparted into the subsurface formation by one or more of signal source32. Seismic energy, for example, may originate from signal source 32, oran array of such signal sources, deployed in body of water 15 and towedby survey vessel 10.

In some embodiments, geophysical sensors 22 (which may also be referredto as receivers) are configured to store data until they are physicallyretrieved, at which point the stored data may be accessed. In otherembodiments, geophysical sensors 22 may be configured to communicatewith survey equipment onshore or in survey vessel wirelessly or usingtransmission cables, in various embodiments. Geophysical sensors 22 mayinclude relatively stable and/or synchronized clocks to timestamprecorded data. Geophysical sensors 22 may be comprised in ocean bottomcables (OBC) and linked together or may be ocean bottom nodes (OBN) andbe individual recording systems (e.g., with a clock, battery, sensor,and data/time recorder integrated within each unit). In the illustratedembodiment, two of geophysical sensors 22 are located distance dl apart.

Survey equipment 12, in one embodiment, includes a computing systemconfigured to, inter alia, process data from geophysical sensors 22. Inother embodiments, a computing system at another location may performgeophysical analysis on data gathered by geophysical survey system 100(e.g., on land after a survey has been conducted). The computing systemmay include or be configured to access a non-transitory storage mediumhaving instructions stored thereon that are executable to cause thesystem to perform various operations described herein. The computingsystem may include one or more processors configured to execute theprogram instructions and one or more data storage devices for storingresults in a tangible medium.

The pattern of an array of seabed sensors for a survey may be determinedin advance in order to generate data usable to perform the disclosedgeophysical analysis techniques. The pattern may specify distancesbetween sensors, sensor orientation, shot area, and other parameters.

FIG. 2 depicts an exemplary array of seabed sensors in accordance withan embodiment of the invention. As depicted, this exemplary arrayincludes 380 sensors in a “raster-shaped” layout pattern. For purposesof illustration, the numbers depicted indicate the seabed positions ofsensors #1, #50, #100, #165, #235, #305 and #380. This layout patternmay be particularly useful in separated wavefield imaging by multiples(SWIM).

Exemplary Method Combining Data from Multiple Surveys for 3-DimensionalStructural Imaging

FIG. 3 is a flow chart of a method 300 using seabed sensors and seasurface reflections for structural imaging of a subsurface location in ageological formation in accordance with an embodiment of the invention.The method 300 combines data from multiple surveys. The steps of FIG. 3are discussed below in relation to the exemplary case illustrated inFIGS. 4A-4E.

As described below, FIGS. 4A-4E illustrate the method steps of FIG. 3used to acquire seismic data in multiple surveys (A and B) and processthe acquired data in combination to image a subsurface location P in asubsurface region 29. The subsurface region 29 may be difficult orimpossible to image using the data from either survey alone due to thegeometries of the shot locations relative to the sensor positions.Nevertheless, the subsurface region 29 may be imaged in three-dimensions(3D imaging) using the method described below for multiple subsurfacepoints in the subsurface region 29.

Per step 302-A, a first marine seismic survey (survey A) may beperformed. The performance of survey A involves generating seismicsignals at a first set of positions and recording a first set ofreceived signals using an array of seabed sensors.

An illustrative example of the first survey (survey A) is shown in FIG.4A. Shown in FIG. 4A are: shot locations of survey A beneath the seasurface 11, and seabed sensors 22 on the sea floor 25.

Per step 302-B, a second marine seismic survey (survey B) may beperformed. The performance of survey B involves generating seismicsignals at a second set of positions and recording a second set ofreceived signals using the same array (location) of seabed sensors.

An illustrative example of the second survey (survey B) is shown in FIG.4B. Shown in FIG. 4B are: shot locations of survey B beneath the seasurface 11, and the array of seabed sensors 22 on the sea floor 25. Notethat, in accordance with the illustrated embodiment, the locations ofthe seabed sensors location 22 do not change between surveys A and B.

Per step 303, up-going and down-going wavefields are separated for eachsurvey. In an exemplary implementation, this may be accomplished bycomputing the summation and difference between the pressure (P) andparticle velocity (Z) fields. Because the up-going wavefield is in-phasefor both pressure and particle-velocity records, the up-going wavefieldmay be extracted by summing the two measurements (PZ-summation) aftercalibration. The down-going wavefield is canceled in the PZ-summationbecause it is out-of-phase on the P field compared to the Z field. Thedown-going wavefield may be extracted by determining the differencebetween the P field and the calibrated Z field.

Per step 304, wavefield A from survey A and wavefield B from survey Bare selected. Each selected wavefield originates at a shot location andends at a sensor.

As illustrated in FIG. 4C, the selected wavefield B originates at shotlocation B_(k) from survey B and travels downward. Wavefield B reflectsfrom subsurface point P in the subsurface region 29 so as to travelupward, then reflects from point r_(B) of the sea surface 11 so as totravel downward. Wavefield B may then reflect from the sea floor 25 soas to travel upward, then reflect from the sea surface 11 again totravel downward until it is detected by a seabed sensor at seabedposition S_(i).

As further illustrated in FIG. 4C, the selected wavefield A originatesat shot location A_(j) and travels downward. Wavefield A may reflectfrom the sea floor 25 so as to travel upward, then reflect from the seasurface 11 to travel downward until it is detected by the seabed sensorat the same seabed position S_(i) as that which detected wavefield B.Note that the first sea-surface reflection point r_(B) of wavefield Bmay be located at shot location A_(j) from survey A. Alternatively, awavefield interpolation process may be performed to obtain acorrespondence between the first sea-surface reflection point r_(B) ofwavefield B and the shot location A from survey A.

Per step 306, the source and sensor definitions of wavefield A may beinterchanged to obtain virtual wavefield A, and source and sensordefinitions of wavefield B may be interchanged to obtain virtualwavefield B. The resultant virtual wavefields A and B are illustrated inFIG. 4D.

As depicted in FIG. 4D, virtual wavefield A originates at virtual sourcelocation 402 at location Si, travels upward to be reflected downward bythe sea surface 11, travels downward until reflected upward by the seafloor 25, and travels upward to be detected by the first (intermediate)virtual sensor 404 at location A_(j). As further depicted, virtualwavefield B originates at virtual source location 402 at location Si,travels upward to be reflected downward by the sea surface 11, travelsdownward until reflected upward by the sea floor 25, travels upward tobe reflected downward at reflection location r_(B), travels downward tobe reflected upward at subsurface location P, and travels upward to bedetected by the second (final) virtual sensor 406 at location B_(k).

Per step 308, the subsurface location in the geological formation ofinterest may be imaged, either using a deconvolution orcross-correlation imaging process. In one embodiment, the geophysicalanalysis equipment may be configured to deconvolve virtual wavefield Busing virtual wavefield A to obtain deconvolved virtual wavefield B/A.The deconvolved virtual wavefield B/A may be effectively used as theimaging wavefield signal 410.

As depicted in FIG. 4E, the imaging wavefield signal 410 may beconsidered as originating at a virtual source 412 at location A_(j)(which is effectively the same as, or made to correspond with, r_(B)),traveling downward to be reflected upward at the subsurface location P,and traveling upward to be detected by the virtual sensor 414 atlocation B_(k).

In an alternate embodiment, the geophysical analysis equipment may beconfigured to perform cross-correlation in order to image subsurfacelocation P. In this embodiment, a first data signal may be the datasignal received at the first (intermediate) virtual sensor 404 atlocation A_(j), and a second data signal may be the data signal receivedat the second (final) virtual sensor 406 at location B_(k). Thecross-correlation of the first data signal and the second data signalmay provide the medium response (i.e., the Green's function) of thesubsurface location P. The result is similar to imaging using a virtualsource-receiver pair, where the virtual source 412 and virtual receiver414 (shown in FIG. 4E) are located at the positions of the virtualsensors 404 and 406, respectively (shown in FIG. 4D).

Per step 310, the resultant image data and other pertinent data isstored in a tangible, non-volatile data storage medium. Tangible mediumholding such image and other pertinent data may subsequently be providedas a geophysical data product.

Missing Shots Due to Obstruction

As described above, the series of FIGS. 4A-4E illustrates a firstexemplary application of the method 300 where a subsurface region 29 maybe difficult or impossible to image using the data from either surveyalone. Similarly, the series of FIGS. 5A-5E illustrates a secondexemplary application of the method 300 where an obstruction at the seasurface blocks shot locations such that one survey has missing shots.

Like FIG. 4A, FIG. 5A depicts an illustrative example of a first seismicsurvey (A) in accordance with an embodiment of the invention. Shown inFIG. 5A are: shot locations of survey A beneath the sea surface 11, andseabed sensors 22 on the sea floor 25.

FIG. 5B depicts a second seismic survey (B) in the presence of a surfaceobstruction B in accordance with an embodiment of the invention. Thesurface obstruction B may be, for example, an offshore productionplatform, an offshore drilling platform, or a drillship. As depicted,the surface obstruction B blocks one or more shot locations that wereplanned to be taken during survey B.

FIG. 5C depicts wavefields from the first and second seismic surveys (Aand B) that are utilized in combination to image a subsurface location(P) that may be underneath the obstruction in accordance with anembodiment of the invention. FIG. 5C in the series of FIGS. 5A-5Ecorresponds to FIG. 4C in the series of FIGS. 4A-4E.

As illustrated in FIG. 5C, the selected wavefield B originates at shotlocation B_(k) from survey B and travels downward. Wavefield B reflectsfrom subsurface point P in the subsurface region 29 so as to travelupward, then reflects from point n₃ of the sea surface 11 so as totravel downward. Wavefield B may then reflect from the sea floor 25 soas to travel upward, then reflect from the sea surface 11 again totravel downward until it is detected by a seabed sensor at the seabedposition S_(i).

As further illustrated in FIG. 5C, the selected wavefield A originatesat shot location A_(j) and travels downward. Wavefield A may reflectfrom the sea floor 25 so as to travel upward, then reflect from the seasurface 11 to travel downward until it is detected by the seabed sensorat the same seabed position S_(i) as that which detected wavefield B.Note that the first sea-surface reflection point r_(B) of wavefield Bmay be located at shot location A_(j) from survey A. Alternatively, awavefield interpolation process may be performed to obtain acorrespondence between the first sea-surface reflection point r_(B) ofwavefield B and the shot location A_(j) from survey A.

FIG. 5D depicts virtual wavefields after reversal of source and sensordefinitions of FIG. 5C in accordance with an embodiment of theinvention. FIG. 5D in the series of FIGS. 5A-5E corresponds to FIG. 4Din the series of FIGS. 4A-4E.

As depicted in FIG. 5D, virtual wavefield A originates at virtual sourcelocation 502 at location Si, travels upward to be reflected downward bythe sea surface 11, travels downward until reflected upward by the seafloor 25, and travels upward to be detected by the first (intermediate)virtual sensor 504 at location A_(j). As further depicted, virtualwavefield B originates at virtual source location 502 at location Si,travels upward to be reflected downward by the sea surface 11, travelsdownward until reflected upward by the sea floor 25, travels upward tobe reflected downward at reflection location r_(B), travels downward tobe reflected upward at subsurface location P, and travels upward to bedetected by the second (final) virtual sensor 506 at location B_(k).

FIG. 5E depicts the virtual wavefield utilized for imaging thesubsurface location (P) after deconvolution or cross-correlation isapplied to the virtual wavefields of FIG. 5D in accordance with anembodiment of the invention. FIG. 5E in the series of FIGS. 5A-5Ecorresponds to FIG. 4E in the series of FIGS. 4A-4E.

As depicted in FIG. 5E, the imaging wavefield signal 510 may beconsidered as originating at a virtual source 512 at location A_(j)(which is effectively the same as, or made to correspond with, r_(B)),traveling downward to be reflected upward at the subsurface location P,and traveling upward to be detected by the virtual sensor 514 atlocation B_(k). The result is that subsurface location P in thesubsurface region 29 may be imaged, despite the missing shot(s) due tothe obstruction at the sea surface during survey B.

Combining Data from Surveys with Different Shot Intervals

Also similar to the series of FIGS. 4A-4E, the series of FIGS. 6A-6Eillustrates a third exemplary case where two surveys have different shotintervals from each other. Despite the different spacings between theshots, select data signals may be processed in combination as describedbelow.

Like FIG. 4A, FIG. 6A depicts a first seismic survey (A) in accordancewith an embodiment of the invention. Shown in FIG. 6A are: shotlocations of survey A beneath the sea surface 11, and seabed sensors 22on the sea floor 25.

FIG. 6B depicts a second seismic survey (B) with different shotintervals than the first seismic survey (A) in accordance with anembodiment of the invention. In the illustrated example, the shots insurvey B are spaced farther apart than the shots in survey A.

FIG. 6C depicts wavefields from the first and second seismic surveys (Aand B) that are utilized in combination to image a subsurface location(P) in accordance with an embodiment of the invention. FIG. 6C in theseries of FIGS. 6A-6E corresponds to FIG. 4C in the series of FIGS.4A-4E.

As illustrated in FIG. 6C, the selected wavefield B originates at shotlocation B_(k) from survey B and travels downward. Wavefield B reflectsfrom subsurface point P at a subsurface level 30 so as to travel upward,then reflects from point r_(B) of the sea surface 11 so as to traveldownward. Wavefield B may then reflect from the sea floor 25 so as totravel upward, then reflect from the sea surface 11 again to traveldownward until it is detected by a seabed sensor at the seabed positionS_(i).

As further illustrated in FIG. 6C, the selected wavefield A originatesat shot location A_(i) and travels downward. Wavefield A may reflectfrom the sea floor 25 so as to travel upward, then reflect from the seasurface 11 to travel downward until it is detected by the seabed sensorat the same seabed position S, as that which detected wavefield B. Notethat the first sea-surface reflection point r_(B) of wavefield B may belocated at shot location A from survey A. Alternatively, a wavefieldinterpolation process may be performed to obtain a correspondencebetween the first sea-surface reflection point r_(B) of wavefield B andthe shot location A_(j) from survey A.

FIG. 6D depicts virtual wavefields after reversal of source and sensordefinitions of FIG. 6C in accordance with an embodiment of theinvention. FIG. 6D in the series of FIGS. 6A-6E corresponds to FIG. 4Din the series of FIGS. 4A-4E.

As depicted in FIG. 6D, virtual wavefield A originates at virtual sourcelocation 602 at location Si, travels upward to be reflected downward bythe sea surface 11, travels downward until reflected upward by the seafloor 25, and travels upward to be detected by the first (intermediate)virtual sensor 604 at location A_(j). As further depicted, virtualwavefield B originates at virtual source location 602 at location Si,travels upward to be reflected downward by the sea surface 11, travelsdownward until reflected upward by the sea floor 25, travels upward tobe reflected downward at reflection location r_(B), travels downward tobe reflected upward at subsurface location P, and travels upward to bedetected by the second (final) virtual sensor 606 at location B_(k).

FIG. 6E depicts the virtual wavefield utilized for imaging thesubsurface location (P) after deconvolution or cross-correlation isapplied to the virtual wavefields of FIG. 6D in accordance with anembodiment of the invention. FIG. 6E in the series of FIGS. 6A-6Ecorresponds to FIG. 4E in the series of FIGS. 4A-4E.

As depicted in FIG. 6E, the imaging wavefield signal 610 may beconsidered as originating at a virtual source 612 at location A (whichis effectively the same as, or made to correspond with, r_(B)),traveling downward to be reflected upward at the subsurface location P,and traveling upward to be detected by the virtual sensor 614 atlocation B_(k). The result is that subsurface location P at subsurfacelevel 30 may be imaged using a combination of data from surveys A and B.

Exemplary Method Combining Data from Multiple Surveys for 4-DimensionalSurveying

FIG. 7 is a flow chart of a method 700 using seabed sensors and seasurface reflections for four-dimensional (4D) surveying for reservoirproduction monitoring in accordance with an embodiment of the invention.The steps 702-728 of FIG. 7 are discussed below in relation to theexemplary case illustrated in FIGS. 8A-8I.

Per step 702, a first marine seismic survey (survey A) may be performed.The performance of survey A involves generating seismic signals at afirst set of positions and recording a first set of received signalsusing an array of seabed sensors. An illustrative example of the firstsurvey (survey A) is shown in FIG. 8A. Shown in FIG. 8A are: shotlocations of survey A beneath the sea surface 11, and seabed sensors 22on the sea floor 25.

Per step 704, after separating up-going and down-going wavefields,wavefields A0 and A1 from survey A are selected. As depicted in FIG. 8A,the two wavefields A0 and A1 originate at different shot locations andend at the same sensor. The selected wavefield A1 originates at shotlocation A_(k) from survey A and travels downward. Wavefield A1 reflectsfrom subsurface point P in the reservoir 31 so as to travel upward, thenreflects from point r₁ of the sea surface 11 so as to travel downward.Wavefield A1 may then reflect from the sea floor 25 so as to travelupward, then reflect from the sea surface 11 again to travel downwarduntil it is detected by a seabed sensor at the seabed position S_(i).The selected wavefield A0 originates at shot location A_(j) and travelsdownward. Wavefield A0 may reflect from the sea floor 25 so as to travelupward, then reflect from the sea surface 11 to travel downward until itis detected by the seabed sensor at the same seabed position S_(i) asthat which detected wavefield A1. Note that the first sea-surfacereflection point r₁ of wavefield A1 may be located at shot locationA_(j) from survey A0. Alternatively, a wavefield interpolation processmay be performed to obtain a correspondence between the firstsea-surface reflection point r₁ of wavefield A1 and the shot locationA_(j) from survey A0.

Per step 706, the source and sensor definitions of wavefield A0 may beinterchanged to obtain virtual wavefield A0, and source and sensordefinitions of wavefield A1 may be interchanged to obtain virtualwavefield A1. FIG. 8B depicts virtual wavefields after reversal ofsource and sensor definitions of FIG. 8A in accordance with anembodiment of the invention. As depicted in FIG. 8B, virtual wavefieldA0 originates at virtual source location 802 at location Si, travelsupward to be reflected downward by the sea surface 11, travels downwarduntil reflected upward by the sea floor 25, and travels upward to bedetected by the first (intermediate) virtual sensor 804 at locationA_(j). As further depicted, virtual wavefield A1 originates at virtualsource location 802 at location Si, travels upward to be reflecteddownward by the sea surface 11, travels downward until reflected upwardby the sea floor 25, travels upward to be reflected downward atreflection location r₁, travels downward to be reflected upward atsubsurface location P, and travels upward to be detected by the second(final) virtual sensor 806-A at location A_(k).

Per step 708, the subsurface location P in the reservoir 31 may beimaged, either using a deconvolution or cross-correlation imagingprocess. The resultant image data and other pertinent data may be storedin a tangible medium so as to be provided as a geophysical data product.

In one embodiment, the geophysical analysis equipment may be configuredto deconvolve virtual wavefield A1 using virtual wavefield A0 to obtaindeconvolved virtual wavefield A1/A0. The deconvolved virtual wavefieldA1/A0 may be effectively used as the imaging wavefield signal 810. Asdepicted in FIG. 8C, the imaging wavefield signal 810 may be consideredas originating at a virtual source 812 at location A_(j) (which iseffectively the same as, or made to correspond with, r₁), travelingdownward to be reflected upward at the subsurface location P, andtraveling upward to be detected by the virtual sensor 814 at locationA_(k).

In an alternate embodiment, the geophysical analysis equipment (onvessel or on shore) may be configured to perform cross-correlation inorder to image subsurface location P. In this embodiment, a first datasignal may be the virtual data signal received at the first virtualsensor at location A_(j), and a second data signal may be the virtualdata signal received at the second virtual sensor at location A_(k). Thecross-correlation of the first data signal and the second data signalmay provide the medium response (i.e., the Green's function) of thesubsurface location P. The result is similar to imaging using a virtualsource-receiver pair, where the virtual source 812 and virtual receiver814 (shown in FIG. 8C) are located at the positions of the first andsecond virtual sensors, respectively.

Per step 712, after a first time gap, a second marine seismic survey(survey B) may be performed. The performance of survey B involvesgenerating seismic signals at a second set of positions and recording asecond set of received signals. Survey B may use an array of seabedsensors at the same positions as the array used in survey A. The seabedsensors in the array for survey B may be the same sensors as used forsurvey A, or the seabed sensors in the array for survey B may beredeployed into the same positions as the sensors used for survey A. Inan exemplary implementation, survey B may use a sparser shot patternthan survey A. One exemplary shot location B_(k) of the second survey(survey B) is shown in FIG. 8D. The shot location B_(k) of survey B isat the same location, or effectively the same location, as the shotlocation A_(k) of survey A.

Per step 714, after separating up-going and down-going wavefields,wavefields A0 of survey A and B1 from survey B are selected. As depictedin FIG. 8D, the two wavefields A0 and B1 originate at different shotlocations and end at the same sensor position. The selected wavefield B1originates at shot location B_(k) from survey B and travels downward.Wavefield B1 reflects from subsurface point P in the reservoir 31 so asto travel upward, then reflects from point r₁ of the sea surface 11 soas to travel downward. Wavefield B1 may then reflect from the sea floor25 so as to travel upward, then reflect from the sea surface 11 again totravel downward until it is detected by a seabed sensor at the seabedposition S_(i). The selected wavefield A0 originates at shot locationA_(j) and travels downward. Wavefield A0 may reflect from the sea floor25 so as to travel upward, then reflect from the sea surface 11 totravel downward until it is detected by the seabed sensor at the sameseabed position S_(i) as that which detected wavefield B1. Note that thefirst sea-surface reflection point r₁ of wavefield B1 may be located atshot location A_(j) from survey A0. Alternatively, a wavefieldinterpolation process may be performed to obtain a correspondencebetween the first sea-surface reflection point r₁ of wavefield B1 andthe shot location A_(j) from survey A0.

Per step 716, the source and sensor definitions of wavefield A0 may beinterchanged to obtain virtual wavefield A0, and source and sensordefinitions of wavefield B1 may be interchanged to obtain virtualwavefield B1. FIG. 8E depicts virtual wavefields after reversal ofsource and sensor definitions of FIG. 8D in accordance with anembodiment of the invention. As depicted in FIG. 8E, virtual wavefieldA0 originates at virtual source location 802 at location S_(i), travelsupward to be reflected downward by the sea surface 11, travels downwarduntil reflected upward by the sea floor 25, and travels upward to bedetected by the first (intermediate) virtual sensor 804 at locationA_(j). As further depicted, virtual wavefield B1 originates at virtualsource location 802 at location Si, travels upward to be reflecteddownward by the sea surface 11, travels downward until reflected upwardby the sea floor 25, travels upward to be reflected downward atreflection location r₁, travels downward to be reflected upward atsubsurface location P, and travels upward to be detected by the second(final) virtual sensor 806-B at location B_(k).

Per step 718, the subsurface location P in the reservoir 31 may beimaged, either using a deconvolution or cross-correlation imagingprocess. Comparison may then be made of the current image data of thesubsurface location P generated in step 718 against the previous imagedata of the subsurface location P generated in step 708. The comparisonmay involve generating difference data by taking a difference betweenthe current and previous image data. The resultant image data,difference data, and other pertinent data may be stored in a tangiblemedium so as to be provided as a geophysical data product.

In one embodiment, the geophysical analysis equipment (on vessel or onshore), which uses a computer system to process the seismic data, may beconfigured to deconvolve virtual wavefield B1 using virtual wavefield A0to obtain deconvolved virtual wavefield B1/A0. The deconvolved virtualwavefield B1/A0 may be effectively used as the imaging wavefield signal820. As depicted in FIG. 8F, the imaging wavefield signal 820 may beconsidered as originating at a virtual source 822 at location A_(j)(which is effectively the same as, or made to correspond with, r₁),traveling downward to be reflected upward at the subsurface location P,and traveling upward to be detected by the virtual sensor 824 atlocation B_(k).

In an alternate embodiment, the geophysical analysis equipment (onvessel or on shore), which uses a computer system to process the seismicdata, may be configured to perform cross-correlation in order to imagesubsurface location P. In this embodiment, a first data signal may bethe virtual data signal received at the first virtual sensor at locationA_(j), and a second data signal may be the virtual data signal receivedat the second virtual sensor at location B_(k). The cross-correlation ofthe first data signal and the second data signal may provide the mediumresponse (i.e., the Green's function) of the subsurface location P. Theresult is similar to imaging using a virtual source-receiver pair, wherethe virtual source 822 and virtual receiver 824 (shown in FIG. 8F) arelocated at the positions of the first and second virtual sensors,respectively.

Per step 722, after a second time gap, a third marine seismic survey(survey C) may be performed. The performance of survey C involvesgenerating seismic signals at a third set of positions and recording athird set of received signals. Survey C may use an array of seabedsensors at the same positions as the array used in survey A. The seabedsensors in the array for survey C may be the same sensors as used forsurvey A, or the seabed sensors in the array for survey C may beredeployed into the same positions as the sensors used for survey A. Inan exemplary implementation, survey C may use a sparser shot patternthan survey A. One exemplary shot location C_(k) of the third survey(survey C) is shown in FIG. 8G. The shot location C_(k) of survey C isat the same location, or effectively the same location, as the shotlocation A_(k) of survey A.

Per step 724, after separating up-going and down-going wavefields,wavefields A0 of survey A and C1 from survey C are selected. As depictedin FIG. 8G, the two wavefields A0 and C1 originate at different shotlocations and end at the same sensor position. The selected wavefield C1originates at shot location C_(k) from survey C and travels downward.Wavefield C1 reflects from subsurface point P in the reservoir 31 so asto travel upward, then reflects from point r₁ of the sea surface 11 soas to travel downward. Wavefield C1 may then reflect from the sea floor25 so as to travel upward, then reflect from the sea surface 11 again totravel downward until it is detected by a seabed sensor at seabedposition S_(i). The selected wavefield A0 originates at shot locationA_(j) and travels downward. Wavefield A0 may reflect from the sea floor25 so as to travel upward, then reflect from the sea surface 11 totravel downward until it is detected by the seabed sensor at the sameseabed position S_(i) as that which detected wavefield C1. Note that thefirst sea-surface reflection point r₁ of wavefield C1 may be located atshot location A_(j) from survey A0. Alternatively, a wavefieldinterpolation process may be performed to obtain a correspondencebetween the first sea-surface reflection point r₁ of wavefield C1 andthe shot location A_(j) from survey A0.

Per step 726, the source and sensor definitions of wavefield A0 may beinterchanged to obtain virtual wavefield A0, and source and sensordefinitions of wavefield C1 may be interchanged to obtain virtualwavefield C1. FIG. 8H depicts virtual wavefields after reversal ofsource and sensor definitions of FIG. 8G in accordance with anembodiment of the invention. As depicted in FIG. 8H, virtual wavefieldA0 originates at virtual source location 802 at location Si, travelsupward to be reflected downward by the sea surface 11, travels downwarduntil reflected upward by the sea floor 25, and travels upward to bedetected by the first (intermediate) virtual sensor 804 at locationA_(j). As further depicted, virtual wavefield C1 originates at virtualsource location 802 at location Si, travels upward to be reflecteddownward by the sea surface 11, travels downward until reflected upwardby the sea floor 25, travels upward to be reflected downward atreflection location r₁, travels downward to be reflected upward atsubsurface location P, and travels upward to be detected by the second(final) virtual sensor 806-C at location C_(k).

Per step 728, the subsurface location P in the reservoir 31 may beimaged, either using a deconvolution or cross-correlation imagingprocess. Comparison may then be made of the current image data of thesubsurface location P generated in step 728 against the previous imagedata of the subsurface location P generated in step 708 or 718. Thecomparison may involve generating difference data by taking a differencebetween the current and previous image data. The resultant image data,difference data, and other pertinent data may be stored in a tangiblemedium so as to be provided as a geophysical data product.

In one embodiment, the geophysical analysis equipment (on vessel or onshore), which uses a computer system to process the seismic data, may beconfigured to deconvolve virtual wavefield C1 using virtual wavefield A0to obtain deconvolved virtual wavefield C1/A0. The deconvolved virtualwavefield C1/A0 may be effectively used as the imaging wavefield signal830. As depicted in FIG. 8I, the imaging wavefield signal 830 may beconsidered as originating at a virtual source 832 at location A_(j)(which is effectively the same as, or made to correspond with, r₁),traveling downward to be reflected upward at the subsurface location P,and traveling upward to be detected by the virtual sensor 834 atlocation C_(k).

In an alternate embodiment, the geophysical analysis equipment (onvessel or on shore), which uses a computer system to process the seismicdata, may be configured to perform cross-correlation in order to imagesubsurface location P. In this embodiment, a first data signal may bethe virtual data signal received at the first virtual sensor at locationA_(j), and a second data signal may be the virtual data signal receivedat the second virtual sensor at location C_(k). The cross-correlation ofthe first data signal and the second data signal may provide the mediumresponse (i.e., the Green's function) of the subsurface location P. Theresult is similar to imaging using a virtual source-receiver pair, wherethe virtual source 832 and virtual receiver 834 (shown in FIG. 8I) arelocated at the positions of the first and second virtual sensors,respectively.

The method 700 of FIG. 7 may continue with the performance andprocessing of further surveys (D, E, F, etc.). Each survey and thesubsequent processing steps results in a “snapshot” image of thereservoir being monitored.

Note that the time gap between survey A and survey B may be typically ofsufficient length for a change to be expected in the state of thereservoir 31. For example, the time gap between surveys A and B may bethree months, six months, or a year, or longer. Similarly, the time gapbetween survey B and survey C may be typically of sufficient length fora change to be expected in the state of the reservoir 31. For example,the time gap between surveys B and C may be three months, six months, ora year, or longer. And so on for further surveys to monitor ahydrocarbon reservoir over a span of years.

The above-described method 700 of FIG. 7 may be used to efficientlymonitor a production reservoir (i.e. perform a 4D survey). Theabove-described method 700 of FIG. 7 provides greater flexibility forsubsequent shooting monitor surveys.

In one use case, while the first survey (survey A) may have a dense shotpattern for detailed 3D imaging, the subsequent surveys (survey B1,survey C, etc.) may have a sparser shot pattern. In a specificimplementation, the first survey may be recorded using a dense singleshot survey, while the subsequent surveys may be recorded usingcost-effective dual-source flip-flop acquisition.

By using the dense shooting geometry of the base-line survey A as the“forward extrapolated” wavefield A0 in combination of different recordedsource wavefields A1, B1, C1, etc. as the “backward extrapolated”wavefield, the difference in the images may be used to provide a 4Dsignal corresponding to reservoir changes within the time gaps betweenacquisitions. A time-lapse imaging sequence may be defined as: Base(A1/A0); Monitor1 (B1/A0); Monitor2 (C1/A0), etc.

Computer Apparatus

FIG. 9 shows a simplified example of a computer apparatus 40 which maybe used in performing processing steps in accordance with an embodimentof the invention. The computer apparatus 40 may be configured withexecutable instructions so as to perform the data processing methodsdescribed herein. This figure shows just one simplified example of acomputer which may be used to perform the data processing methodsdescribed herein. Other types of computers may also be employed. As alarge amount of seismic data is typically processed, a high-performancecluster of multi-processor server computers may be used in practice. Theprocessing methods may also be performed using a cloud computing system.

As depicted in FIG. 9, the simplified example of the computer apparatus40 may include a processor 41, such as those from the Intel Corporationof Santa Clara, Calif., for example. The computer apparatus 40 may havea bus system 43 communicatively interconnecting its various components.The computer apparatus 40 may include one or more user input devices 42(e.g., keyboard, mouse), a display monitor 44 (e.g., LCD, flat panelmonitor, CRT), a computer network interface 45 (e.g., network adapter,modem), and a data storage system which may include one or more datastorage devices 46 (e.g., hard drive, solid state memory, optical diskdrive, USB memory) and a main memory 50 (e.g., RAM).

In the example shown in this figure, the main memory 50 includesexecutable code 52 and data 54 stored therein. The executable code 52may comprise computer-readable program code (i.e., software) componentswhich may be loaded from the data storage device 46 to the main memory50 for execution by the processor 41. In particular, the executable code52 may be configured to perform computer-implemented steps in themethods described herein.

Although specific embodiments have been described above, theseembodiments are not intended to limit the scope of the presentdisclosure, even where only a single embodiment is described withrespect to a particular feature. Examples of features provided in thedisclosure are intended to be illustrative rather than restrictiveunless stated otherwise. The above description is intended to cover suchalternatives, modifications, and equivalents as would be apparent to aperson skilled in the art having the benefit of this disclosure.

The scope of the present disclosure includes any feature or combinationof features disclosed herein (either explicitly or implicitly), or anygeneralization thereof, whether or not it mitigates any or all of theproblems addressed herein. Accordingly, new claims may be formulatedduring prosecution of this application (or an application claimingpriority thereto) to any such combination of features. In particular,with reference to the appended claims, features from dependent claimsmay be combined with those of the independent claims and features fromrespective independent claims may be combined in any appropriate mannerand not merely in the specific combinations enumerated in the appendedclaims.

What is claimed is:
 1. A method of four-dimensional marine seismic imaging, the method comprising: obtaining first received signals recorded by a first array of sensors in a first seismic survey in which seismic signals were generated at a first set of shot locations; generating first image data of a subsurface location using the first received signals, wherein generating the first image data of the subsurface location comprises using first and second wavefields from the first seismic survey, wherein the first wavefield originates at a first shot location and is detected at a seabed sensor position and the second wavefield originates at a second shot location, reflects from the subsurface location, and is detected at the seabed sensor position; obtaining second received signals recorded by a second array of sensors in a second seismic survey in which seismic signals were generated at a second set of shot locations, wherein the second array of sensors has sensors at the same positions as the first array of sensors; generating second image data of the subsurface location using a combination of the first and second received signals; and monitoring the subsurface location by comparing the first and second image data.
 2. The method of claim 1, wherein generating the second image data of the subsurface location comprises using the first wavefield from the first seismic survey and a third wavefield from the second seismic survey.
 3. The method of claim 2, wherein the third wavefield originates at the second shot location, reflects from a sea surface at the first shot location, and is detected at the seabed sensor position.
 4. The method of claim 1, wherein there is a time gap of at least three months between the first and second seismic surveys.
 5. The method of claim 1 further comprising: obtaining third received signals recorded by a third array of sensors in a third seismic survey in which seismic signals were generated at a third set of shot locations, wherein the third array of sensors has sensors at the same positions as the first array of sensors; and generating third image data of the subsurface location using a combination of the first and third received signals.
 6. The method of claim 5, wherein generating the third image data of the subsurface location comprises using the first wavefield from the first seismic survey and a fourth wavefield from the third seismic survey.
 7. The method of claim 6, wherein the fourth wavefield originates at the third shot location, reflects from the sea surface at the first shot location, and is detected at the seabed sensor position.
 8. The method of claim 5, wherein there is a time gap of at least three months between the first and second seismic surveys, and wherein there is a time gap of at least three months between the second and third seismic surveys.
 9. A method of manufacturing a geophysical data product, the method comprising: obtaining first received signals recorded by an array of sensors in a first seismic survey in which seismic signals were generated at a first set of shot locations; generating first image data of a subsurface location using the first received signals, wherein generating the first image data of the subsurface location comprises using first and second wavefields from the first seismic survey, wherein the first wavefield originates at a first shot location and is detected at a seabed sensor position and the second wavefield originates at a second shot location, reflects from the subsurface location, and is detected at the seabed sensor position; obtaining second received signals recorded by the array of sensors in a second seismic survey in which seismic signals were generated at a second set of shot locations; generating second image data of the subsurface location using a combination of the first and second received signals; generating difference data from the first and second image data so as to determine a change in the subsurface location; and storing the difference data in a tangible medium.
 10. The method of claim 9, wherein generating the second image data of the subsurface location comprises using the first wavefield from the first seismic survey and a third wavefield from the second seismic survey.
 11. The method of claim 10, wherein the third wavefield originates at the second shot location, reflects from a sea surface at the first shot location, and is detected at the seabed sensor position
 12. The method of manufacturing of claim 9, wherein there is a time gap of at least three months between the first and second seismic surveys.
 13. A system for four-dimensional marine seismic imaging, the system comprising: a first array of sensors arranged to obtain first received signals recorded in a first seismic survey in which seismic signals were generated at a first set of shot locations; executable instructions stored in a tangible medium which are executable by a computer apparatus and are configured to generate first image data of a subsurface location using the first received signals, wherein the executable instructions use first and second wavefields from the first seismic survey to generate the first image data of the subsurface location, wherein the first wavefield originates at a first shot location and is detected at a seabed sensor position and the second wavefield originates at a second shot location, reflects from the subsurface location, and is detected at the seabed sensor position; a second array of sensors arranged to obtain second received signals recorded in a second seismic survey in which seismic signals were generated at a second set of shot locations, wherein the second array of sensors has sensors at the same positions as the first array of sensors; executable instructions stored in a tangible medium which are executable by the computer apparatus and are configured to generate second image data of the subsurface location using a combination of the first and second received signals; and executable instructions stored in a tangible medium which are executable by the computer apparatus and are configured to monitor the subsurface location by comparing the first and second image data.
 14. The system of claim 13, wherein the second image data of the subsurface location is generated by the executable instructions using the first wavefield from the first seismic survey and a third wavefield from the second seismic survey.
 15. The system of claim 14, wherein the third wavefield originates at the second shot location, reflects from a sea surface at the first shot location, and is detected at the seabed sensor position.
 16. The system of claim 13, wherein there is a time gap of at least three months between the first and second seismic surveys.
 17. The system of claim 13, further comprising: a third array of sensors arranged to obtain third received signals recorded in a third seismic survey in which seismic signals were generated at a third set of shot locations, wherein the third array of sensors has sensors at the same positions as the first array of sensors; and executable instructions stored in a tangible medium which are executable by the computer apparatus and are configured to generate third image data of the subsurface location using a combination of the first and third received signals.
 18. The system of claim 17, wherein the third image data of the subsurface location is generated by the executable instructions using the first wavefield from the first seismic survey and a fourth wavefield from the third seismic survey.
 19. The system of claim 18, wherein the fourth wavefield originates at the third shot location, reflects from the sea surface at the first shot location, and is detected at the seabed sensor position.
 20. The system of claim 17, wherein there is a time gap of at least three months between the first and second seismic surveys, and wherein there is a time gap of at least three months between the second and third seismic surveys. 